CN111119815A - Method for determining production well production allocation ratio through balanced displacement - Google Patents
Method for determining production well production allocation ratio through balanced displacement Download PDFInfo
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
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- E—FIXED CONSTRUCTIONS
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- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
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Abstract
The invention relates to the technical field of oilfield development, in particular to a method for determining the production allocation ratio of a production well by balanced displacement. The method comprises the following steps: step 1, determining the distance wave and range of different injection and production wells; step 2, splitting the wave coverage range of the two production well groups in a linear one-injection mode; step 3, determining the remaining recoverable reserves in the range of the group sweep of each injection well; and 4, determining the production allocation ratio of different production wells. The method can achieve the aims of finally balancing displacement and improving the recovery ratio.
Description
Technical Field
The invention relates to the technical field of oilfield development, in particular to a method for determining the production allocation ratio of a production well by balanced displacement.
Background
Due to the strong plane heterogeneity of the low-permeability reservoir, the water content difference is large, the plane displacement is unbalanced, the plane extraction degree difference is large, and residual oil in part of wells is enriched.
Balanced displacement means that the degree of displacement is the same in all directions of the formation. Actual reservoirs cannot realize complete balanced displacement, and only can realize partial balanced displacement. If the displacement degrees in the direction of connecting lines of all injection wells and production wells of the stratum are equal, the displacement is called (partial) balanced displacement. Due to the influence of the difference of parameters such as injection-production well spacing, water content, plane physical properties and the like, plane equilibrium displacement is difficult to achieve. Through reasonable production allocation and injection allocation research, the maximum balanced displacement is realized, so that the oil field development effect is improved, and the recovery rate is finally improved.
The current research on the production allocation and injection allocation optimization of oil-water wells mainly comprises the following steps: liu De Hua and the like determine the production parameters of each production well on a block by a grey prediction method, and then determine the reasonable injection amount of each water injection well according to the injection-production balance principle and the incidence matrix among the wells on the block (application of Liu De Hua, Zhang Li Min. grey system method in oilfield development. system engineering, 1993; 11(4): 52-59); the method comprises the following steps of (1) carrying out calculation on reasonable water distribution of a water injection well by using a plane splitting coefficient method instead of a conventional KH method or an H method for a stone dawn canal and the like (stone dawn canal, Madao Xiang. research on a calculation method for reasonable water distribution and injection quantity of the water injection well, western prospecting engineering, 2008; 9: 94-96); the method for improving the unbalance of the oil field development plane is provided (Qiubun attitude, Jingguo super, Dongku, etc. the practice and application of injection-production structure adjustment in the later development stage of extra high water content of the double river oil field, Henan Petroleum, 2002; 16(2): 18-20); the relation between the stratum pressure change and the injection-production structure adjustment is obtained by numerical simulation of Zhao Chunseng and the like, and the influence of the injection-production structure on the development effect is determined (Zhao Chunseng, Li Chenglong, Zhang Dan. research on the influence of the injection-production structure on the development effect is determined by using the numerical simulation result, scientific technology and engineering, 2011; 11(34): 8577-8581). The technical scheme is that the method comprises the steps of providing a standard of balanced displacement in an extra-high water cut period by a person with a high intelligence transfer rate and aiming at the condition that one-injection two-production well group and two-injection one-production well group in a fault block oil reservoir are unbalanced in use between two injection and production wells in the extra-high water cut period, carrying out production allocation and injection allocation optimization research on the well groups under the condition of different reservoir heterogeneities, and establishing a water injection amount or liquid amount distribution proportion chart for the two well groups to achieve balanced displacement within a given regulation and control time under the condition of different heterogeneity reservoir layers. The research results are applied to the injection and production allocation of the actual well group, and a better development effect is achieved (the research on the allocation and injection optimization of the typical well group in the ultra-high water-cut period of the fault block oil reservoir [ J ] scientific technology and engineering, 2013(03): 159-.
At present, test attempts in qualitative aspects are mainly carried out on site aiming at the problem, and quantitative research on the liquid production level of a production well is not carried out.
Disclosure of Invention
The invention aims to provide a method for determining the group sweep range of an injection well and a production well under the influence of multiple factors, and a method for determining the production allocation ratio of a production well by balanced displacement is designed on the basis of the method.
In order to achieve the purpose, the invention adopts the following technical scheme: a method of determining a production well stimulation rate for balanced displacement comprising the steps of:
step 1, determining the distance wave and range of different injection and production wells;
step 2, splitting the wave coverage range of the two production well groups in a linear one-injection mode;
step 3, determining the remaining recoverable reserves in the range of the group sweep of each injection well;
and 4, determining the production allocation ratio of different production wells.
Preferably, in the step 1, the injection-production well distance range of the target block is counted, the particle motion trajectories at different injection-production well distances are obtained by using a streamline model, and the swept range of the different injection-production well distances is calculated by using a mathematical method;
preferably, a conceptual model is established to obtain a streamline distribution diagram with different injection-production well distances, the streamline sweep range can be simplified into two elliptic nested mathematical graphs, and the area of the graph is the sweep range of one injection-production well group;
preferably, the interval between different injection-production well intervals is 50-100 m.
Preferably, L is calculatedCO、LHBAnd LFGThree parameters, wherein LCOIs the maximum swept distance, L, in the vertical direction of the midpoint of the injection-production well connecting lineHBThe maximum swept distance, L, of the injection well point along the vertical direction of the injection-production well connecting lineFGThe injection well extends for the maximum distance along the connecting line of the injection well and the production well; and summarizing the change rule of the three parameters along with the injection-production well spacing, regressing an equation, and calculating the wave forming range of one injection well and one production well under the condition of different injection-production well spacing.
Preferably, in step 2, the two injection and production well groups are injected and produced in a straight line, and the common sweep range around the injection well is mathematically split into the sweep ranges of the injection and production well groups.
Preferably, the common swept area may be approximated by two circular regions.
Preferably, in step 3, the remaining recoverable reserves of each injection and production well group are obtained according to the water content condition of the production well and the flow splitting curve obtained by combining the oil-water relative permeability.
Preferably, the method for obtaining the residual recoverable reserves of each injection and production well group comprises the following steps:
①, drawing a water phase flow rate distribution curve, namely obtaining the water content under different water saturation degrees by utilizing a water phase flow rate distribution formula and combining relative permeability data, namely the water phase flow rate distribution curve;
preferably, the aqueous phase split flow formula is:
in the formula (f)wWater content, KroDifferent water saturation SwRelative permeability of the oil phase, KrwDifferent water saturation SwRelative permeability of the aqueous phase,. mu.wWater viscosity at formation conditions, μoViscosity of crude oil at formation conditions, Sw-water saturation;
② calculating the recoverable residual oil saturation,
Syor＝(1-Sor)-(1-Sfw)＝Sfw-Sor
in the formula, Syor-recoverable residual oil saturation; sor-residual oil saturation; sfw-water saturation under current water conditions;
③ calculating the residual recoverable reserves of each injection-production well group
Wherein i ═ 1,2, S'iArea of sweep range, m, of injection-production well group i2；hi-average effective thickness, m, of injection and production well group i; phi is the average porosity of the injection and production well group, decimal; rhooGround crude oil density, kg/m3；Bo-crude oil volume factor, dimensionless quantity;
-recoverable residual oil saturation for injection-production well group i.
Preferably, in step 4, the liquid production level proportion of the production wells of each injection and production well group is determined by combining the water content condition of each production well with the aim that the residual recoverable reserves of each injection and production well group are completely displaced at the same time.
Preferably, the liquid production level ratio of the production wells of the injection and production well group is as follows:
the method is established by aiming at the straight-line one-injection two-production well group, considering the difference of water content, injection and production well spacing and the like, and adjusting the production liquid level of the production well so as to achieve the aim of finally balancing displacement. And (3) counting the range of the injection-production well distance according to the target area, obtaining particle motion tracks at different injection-production well distances by using a streamline model, and calculating the sweep range of the different injection-production well distances by using a mathematical method. For the injection-production well group with one injection and two production in straight line, the common sweep range around the injection well is split into the sweep ranges of the injection-production well groups by a mathematical method. And obtaining a flow splitting curve according to the relative permeability of oil and water, and obtaining the residual recoverable reserves of each injection and production well group by combining the water content condition of the production well. And determining the liquid production level proportion of the production wells of each injection and production well group by taking the aim that the residual recoverable reserves of each injection and production well group are completely displaced at the same time and combining the water-containing conditions of each production well.
The invention comprehensively considers the water content change condition caused by multiple factors such as heterogeneity, process measures, pump detection and the like, can adjust the liquid preparation proportion of the production well in real time, is convenient for on-site calculation operation, and ensures that the maximum balanced displacement can be realized finally.
Drawings
Fig. 1 is a schematic view of a flow line model according to an embodiment of the present invention.
Fig. 2 is a simplified schematic diagram of a beam-injection-production well group sweep range according to an embodiment of the present invention.
Fig. 3 is a simplified schematic diagram of a linear one-injection two-production well group sweep range according to an embodiment of the present invention.
FIG. 4 is a graph of the aqueous phase split flow in an embodiment of the invention.
Detailed Description
It is to be understood that the following detailed description is exemplary and is intended to provide further explanation of the invention as claimed. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of exemplary embodiments according to the invention. As used herein, the singular forms "a", "an" and "the" are intended to include the plural forms as well, and it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of the stated features, steps, operations, and/or combinations thereof, unless the context clearly indicates otherwise.
In order to make the technical solutions of the present invention more clearly understood by those skilled in the art, the technical solutions of the present invention will be described in detail below with reference to specific embodiments.
Embodiment of the method for determining the production well production allocation ratio by balanced displacement
In this embodiment, taking a low permeability reservoir of a victory oil field as an example, the method includes the following steps:
step 1, counting the injection and production well spacing of the low-permeability reservoir of the victory oil field, wherein the injection and production well spacing of the oil field is generally 200-500m, establishing a conceptual model to obtain a streamline distribution diagram (figure 1) with different injection and production well spacings (100 m), wherein the streamline sweep range can be simplified into two elliptic nested mathematical graphs (figure 2), and the area of the graphs is the sweep range of one injection-production well group.
In the flow profile, 3 key parameters for different injection-production well spacing can be measured (table 1), namely: l isCO、LHBAnd LFG(LCOIs the maximum swept distance, L, in the vertical direction of the midpoint of the injection-production well connecting lineHBThe maximum swept distance, L, of the injection well point along the vertical direction of the injection-production well connecting lineFGThe injection well extends a maximum distance along the injection-production well connection).
TABLE 1 statistical table of key parameters of different injection-production well spacing
And (3) summarizing the change rule of the 3 key parameters along with the injection-production well spacing, and regressing an equation.
LCO＝0.39LAB-10
LHB＝0.0003LAB 2+0.067LAB+21.8
LFG＝-0.0002LAB 2+0.296LAB-28.1
Area of a wave range of a group of injection and production wells:
in step 2, the two injection and production well groups are injected linearly, the common swept area can be approximated to two circular areas (fig. 3), and the swept area areas of the two injection and production well groups can be respectively calculated.
And one injection and two production well groups are linearly arranged, and injection and production well distances of 300m and 400m are taken as examples.
And firstly, injecting and extracting 300m well spacing, and substituting a regression formula of key parameters to obtain:
area of wave coverage range of injection-production well group at 300m well spacing:
firstly, injecting and extracting 400m well spacing, and substituting a regression formula of key parameters to obtain:
area of wave coverage range of injection-production well group with 400m well spacing:
the area of the common swept range of the first injection well and the second production well is as follows:
area of the group sweep range of 300m injection-production wells:
area of a 400m injection-production well group sweep range:
in the step 3, a flow splitting curve is obtained by utilizing the relative permeability of oil and water, the water saturation of the production well point at the moment is obtained according to the water-containing condition, the oil saturation is obtained, and the recoverable residual oil saturation is obtained by combining the movable oil saturation. And (3) combining the counted geological parameters of each injection and production well group according to the sweep range of the 2 injection and production well groups calculated in the step (2) to obtain the recoverable reserves of each injection and production well group.
① plotting the split flow curves
The water content calculation formula is as follows:
since the relative permeability ratio of oil and water phases is expressed as a function of water saturation, i.e.:
obtaining:
the water phase flow splitting formula is combined with relative permeability data to obtain different water saturation degrees SwLower water content fwI.e. the aqueous phase split flow curve.
The aqueous phase split flow curves are shown in figure 4.
② calculating recoverable residual oil saturation
The water saturation for different water conditions can be obtained from figure 4.
The water content of the production well is respectively as follows:
the water saturation can be obtained according to the split flow curve.
The water saturation of the production well is respectively as follows:
the saturation of the recoverable residual oil at the injection-production well spacing is calculated as follows:
③ calculating the residual recoverable reserves of each injection-production well group
The average effective thicknesses of the two injection and production well groups are counted as follows:
h1＝8(m)，h2＝6(m)。
the residual recoverable reserves of the two injection and production well groups are respectively as follows:
in the formula, phi represents the average porosity and decimal of the injection and production well group; rhooGround crude oil density, kg/m3；BoCrude oil volume factor, dimensionless quantity.
And 4, determining the liquid production level proportion of the production wells of each injection and production well group by combining the water content condition of each production well with the aim that the residual recoverable reserves of each injection and production well group are completely displaced at the same time.
Time required for the injection-production well group to be completely displaced:
in the formula (I), the compound is shown in the specification,
area of sweep range, m, of each injection-production well group2；hi-average effective thickness, m, of each injection-production well group; phi is the average porosity of the injection and production well group, decimal; rhooGround crude oil density, kg/m3；
The injection and production well group is completely displaced at the same time, t1＝t2I.e. by
Obtaining:
namely the determined liquid production level proportion of the production wells of the injection and production well group.
In conclusion, the invention comprehensively considers the water content change condition caused by multiple factors such as heterogeneity, process measures, pump detection and the like, can adjust the liquid preparation proportion of the production well in real time, is convenient for on-site calculation operation, and ensures that the maximum balanced displacement can be finally realized.
The above embodiments are preferred embodiments of the present invention, but the present invention is not limited to the above embodiments, and any other changes, modifications, substitutions, combinations, and simplifications which do not depart from the spirit and principle of the present invention should be construed as equivalents thereof, and all such changes, modifications, substitutions, combinations, and simplifications are intended to be included in the scope of the present invention.
Claims (9)
1. A method of determining a productive well stimulation rate for balanced displacement, the method comprising:
step 1, determining the distance wave and range of different injection and production wells;
step 2, splitting the wave coverage range of the two production well groups in a linear one-injection mode;
step 3, determining the remaining recoverable reserves in the range of the group sweep of each injection well;
and 4, determining the production allocation ratio of different production wells.
2. The method according to claim 1, wherein in step 1, the range of the injection-production well distance of the target block is counted, the particle motion trajectories at different injection-production well distances are obtained by using a streamline model, and the sweep range of the different injection-production well distances is calculated by using a mathematical method;
preferably, a conceptual model is established to obtain a streamline distribution diagram with different injection-production well distances, the streamline sweep range can be simplified into two elliptic nested mathematical graphs, and the area of the graph is the sweep range of one injection-production well group;
preferably, the interval between different injection-production well intervals is 50-100 m.
3. The method of claim 2, wherein L is calculatedCO、LHBAnd LFGAnd summarizing the change rule of the three parameters along with the injection-production well distance, regressing an equation, and calculating the one-injection-one-production well group wave sum range under the condition of different injection-production well distances.
4. The method of claim 1, wherein in step 2, the two-production injection and production well groups are injected in a straight line, and the common sweep range around the injection well is mathematically split into the sweep ranges of the injection and production well groups.
5. The method of claim 4, wherein the common sweep range is approximated by two circular regions.
6. The method of claim 1, wherein in step 3, the residual recoverable reserve of each injection and production well group is obtained according to the water content of the production well and the obtained flow splitting curve of the oil-water relative permeability.
7. The method of claim 6, wherein the method for obtaining the remaining recoverable reserves of each injection-production well group comprises the steps of:
①, drawing a water phase flow rate distribution curve, namely obtaining the water content under different water saturation degrees by utilizing a water phase flow rate distribution formula and combining relative permeability data, namely the water phase flow rate distribution curve;
preferably, the aqueous phase split flow formula is:
in the formula (f)wWater content, KroDifferent water saturation SwRelative permeability of the oil phase, KrwDifferent water saturation SwRelative permeability of the aqueous phase,. mu.wWater viscosity at formation conditions, μoViscosity of crude oil at formation conditions, Sw-water saturation;
② calculating the recoverable residual oil saturation,
Syor＝(1-Sor)-(1-Sfw)＝Sfw-Sor
in the formula, Syor-recoverable residual oil saturation; sor-residual oil saturation; sfw-water saturation under current water conditions;
③ calculating the residual recoverable reserves of each injection-production well group
Wherein i ═ 1,2, S'iArea of sweep range, m, of injection-production well group i2；hi-average effective thickness, m, of injection and production well group i; phi is the average porosity of the injection and production well group, decimal; rhooGround crude oil density, kg/m3；Bo-crude oil volume factor, dimensionless quantity;
-recoverable residual oil saturation for injection-production well group i.
8. The method of claim 7 wherein the fluid production level ratio of the production wells of each injection and production well group is determined in combination with the water cut status of each production well with the goal that the remaining recoverable reserves of each injection and production well group are simultaneously and completely displaced.
9. The method of claim 8, wherein the fluid production level ratios for the production wells of the injection and production well group are:
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